Abstract
Talbot oilfield was discovered by AC/P12 joint ventures in December 1989. The AC/P12 permit was gazetted for competitive bidding and awarded in February 1989. Work obligation of the permit was composed of the seismic program involving acquistion of 2, 660km of 2-D and 3, 350km of 3-D data, seismic reprocessing and drilling of four wildcat wells. 3-D seismic acquisition covered the C2 prospect, which was delineated as a significant fault-dependent structural high during the bidding study in 1988. Interpretation of this oil field, subsequently named Talbot, revealed tectonic and stratigraphic similarities to the Challis oil field, 40km to the north. The Talbot-1 produced oil and gas at and unstabilized rate of 4, 981 BOPD and 3.71 MMCFGD in December 1989. The Talbot-2 appraisal also produced oil and gas at a maximum unstabilized rate of 4, 992 BOPD and 2.93 MMCFGD in June 1990. By comparison with Challis oil field, the reservoir sandstone of the Talbot oil field was expected to be thick and of excellent quality. However, it was composed of a thin bedded poor reservoir quality sandstone, alternated with siltstone, claystone and dolomite.The purpose of this study was to clarify the structure of Base Cretaceous horizon and upper Triassic reservoir itself together with the oil and gas reserves estimation of the Talbot oil field in detail. The study has clarified the structure of the Talbot oil field including the dip and minor faults of the reservoir section. The 3-D seismic interpretation was one of the most useful methods to evaluate a thin bedded reservoir like the Talbot oil field in detail.
Sign-in/Register to access full text options 
Free) 
Talk to us
Join us for a 30 min session where you can share your feedback and ask us any queries you have
Schedule a call
